Availability
Available to any member of the Cooperative who meets the eligibility criteria set forth herein and is located in the territory served by the Cooperative.
Applicability
Applicable to consumers supplied at a single location who meet the following requirements for service:
- The consumer's monthly maximum demands must be at least 500 kW.
- The consumer takes service directly from a Hoosier Energy supplied transmission-to-distribution substation.
Type of Service
Service shall be three phase, 60 hertz, at available standard voltages.
Monthly Rate
Connection Charge: $150.00 per month
Demand Charge:
Production:
Summer - $ 8.14 per kW of Summer Coincident Peak Demand
Winter - $ 6.89 per kW of Winter Coincident Peak Demand
Transmission - $ 6.13 per kW of Coincident Demand
Substation & Radial Line - $ 5.00 per kW of Billing Non-Coincident Demand
Energy Charges:
On-Peak $ 0.05709 per kwh
Off-Peak $ 0.03845 per kwh
Excess Net kVARh charge $ 0.01009 per kVARh
Summer Coincident Demand
For the months of June through August, Summer Coincident Demand at RSE’s delivery point in the month of billing shall be the delivery point’s clock-hour demand that is coincident with Midcontinent Independent System Operator’s (MISO) system peak demand occurring during Load shall Control Periods within the On-Peak Demand Period, defined as those hours from 7:00 a.m. to 11:00 p.m., E.S.T., daily. The Summer Coincident Demand shall be no less than 500 kW.
For the months of September through November, Summer Coincident Demand is the average of the Summer Coincident Demands for the preceding months of June through August.
Winter Coincident Demand
For the months of December through February, Winter Coincident Demand at RSE’s delivery point in the month of billing shall be the delivery point’s clock-hour demand that is coincident with MISO’s system peak demand occurring during Load shall Control Periods within the On-Peak Demand Period, defined as those hours from 7:00 a.m. to 11:00 p.m., E.S.T., daily. The Winter Coincident Demand shall be no less than 500 kW.
For the months of March through May, Winter Coincident Demand is the average of the Winter Coincident Demands for the preceding months of December through February.
Coincident Demand
For the months of March – May and September – November the Coincident Demand at each delivery point in the month of billing shall be the delivery point’s clock-hour demand that is coincident with Hoosier Energy’s system peak demand, E.S.T., daily.
For the months of June – August and December – February the Coincident Demand at each delivery point in the month of billing shall be the delivery point’s clock-hour demand that is coincident with MISO’s estimated system peak demand, E.S.T., daily.
Non-Coincident Demand
Non-Coincident Demand at each delivery point in the month of billing shall be the delivery point’s highest kW demand for any fixed 30-minute period during the billing month.
Billing Non-Coincident Demand
Billing Non-Coincident Demand at each member delivery point in the month of billing shall be the delivery’s point non-coincident demand adjusted for the power factor as required.
Billing kWh
The billing kWh shall be the actual kwh used during the billing month or 328.5 times the monthly billing demand.
Determination of Energy
On-Peak:
For the months of June through August, excluding Independence Day as defined by the North American Electric Reliability Corporation (NERC), On-Peak energy shall be all kilowatt-hours used during the period 2:00 p.m. to 8:00 p.m. – Monday through Friday, E.S.T., daily.
For the months of December through February, excluding Christmas and New Years Day as defined by NERC, On-Peak Energy shall be all kilowatt-hours used during the periods 7:00 a.m. to 10:00 a.m. and 6:00 p.m. to 9:00 p.m. – Monday through Friday, E.S.T., daily.
Off-Peak:
Off-Peak Energy shall be all kilowatt-hours used during all hours other than on-peak hours as described above.
Power Factory
If the Average Monthly Power Factor (leading or lagging) at the time of the Non-Coincident Demand is determined to be less than 97%, the Non-Coincident Demand shall be adjusted separately by multiplying the Non-Coincident Demand by the ratio of the current target power factor percent (97%) and the measured actual power factor percent at the time of the Non-Coincident Demand.
If the Average Monthly Power Factor (leading or lagging) is determined to be less than 95% the “Excess Net kVARh” subject to the “Excess Net kVARh charge” is the difference between the actual measured Net kVARh amount and a calculated Net kVARh based upon the recorded kWh for the month and the targeted average monthly power factor of 95%. The Net kVARh calculation is based upon the standard Average Monthly Power Factor equation of:
Minimum Monthly Charge
The minimum monthly charge shall be the greater of:
- $2,900 plus the energy charge.
- The sum of the connection charge, demand charge, the energy charge and excess Net kVARh.
Rate Adjustment and Non-recurring Charges
This Rate Schedule is subject to a Wholesale Power Cost Adjustment (“WPCA”) Factor, as provided for in Schedule WPCA, all other applicable rate adjustment mechanisms, Riders, and all non-recurring charges set forth on “Appendix A” which may be amended from time to time in the sole discretion of the Board of Directors.
Terms and Conditions of Service
- The applicant will be required to give satisfactory assurance by means of a written agreement as to the character, amount, and duration of the business offered.
- In general, individual motors rated in excess of twenty (20) horsepower must be three-phase.
- Any transformers and regulation equipment which may be required for incidental lighting shall be furnished by the consumer.
- Electric Service provided hereunder is subject to the provisions set forth in the Cooperative’s Bylaws, Service Rules & Regulations, and Policies, as may be amended from time to time in the sole discretion of the Board of Directors.
- The rates and charges set forth in this Rate Schedule are subject to change at any time in the sole discretion of the Board of Directors.